WO2015147800A1 - Systèmes de surveillance électromagnétique (em) permanent utilisant des électrodes de source couplées de manière capacitive - Google Patents

Systèmes de surveillance électromagnétique (em) permanent utilisant des électrodes de source couplées de manière capacitive Download PDF

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Publication number
WO2015147800A1
WO2015147800A1 PCT/US2014/031731 US2014031731W WO2015147800A1 WO 2015147800 A1 WO2015147800 A1 WO 2015147800A1 US 2014031731 W US2014031731 W US 2014031731W WO 2015147800 A1 WO2015147800 A1 WO 2015147800A1
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WO
WIPO (PCT)
Prior art keywords
source electrode
formation
electrically insulating
insulating layer
electrode
Prior art date
Application number
PCT/US2014/031731
Other languages
English (en)
Inventor
Glenn Andrew WILSON
Burkay Donderici
Original Assignee
Halliburton Energy Services, Inc.
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Halliburton Energy Services, Inc. filed Critical Halliburton Energy Services, Inc.
Priority to CA2940029A priority Critical patent/CA2940029A1/fr
Priority to EP14887671.7A priority patent/EP3102955A4/fr
Priority to PCT/US2014/031731 priority patent/WO2015147800A1/fr
Priority to US15/118,073 priority patent/US10775527B2/en
Priority to AU2014388388A priority patent/AU2014388388B2/en
Publication of WO2015147800A1 publication Critical patent/WO2015147800A1/fr

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Classifications

    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N27/00—Investigating or analysing materials by the use of electric, electrochemical, or magnetic means
    • G01N27/02—Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance
    • G01N27/22—Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance by investigating capacitance
    • G01N27/221—Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance by investigating capacitance by investigating the dielectric properties
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/003—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings with electrically conducting or insulating means
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/10—Locating fluid leaks, intrusions or movements
    • E21B47/113—Locating fluid leaks, intrusions or movements using electrical indications; using light radiations
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
    • E21B47/125—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using earth as an electrical conductor
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V3/00—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation
    • G01V3/18—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation specially adapted for well-logging
    • G01V3/20—Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination, deviation specially adapted for well-logging operating with propagation of electric current

Definitions

  • Oilfield operators are faced with the challenge of maximizing hydrocarbon recovery within a given budget and timeframe. While they perform as much logging and surveying as feasible before and during the drilling and completion of production wells and, in some cases, injection wells, the information gathering process does not end there. It is desirable for the operators to track the movement of fluids in and around the reservoirs, as this information enables them to adjust the distribution and rates of production among the producing and/or injection wells to avoid premature water breakthroughs and other obstacles to efficient and profitable operation. Moreover, such information gathering further enables the operators to better evaluate treatment and secondary recovery strategies for enhanced hydrocarbon recoveries.
  • the fluid saturating the formation pore space is often measured in terms of a hydrocarbon fraction and a water fraction. Due to the solubility and mobility of ions in water, the water fraction lends itself to indirect measurement via a determination of formation resistivity. Thus the ability to remotely determine and monitor formation resistivity is of direct relevance to long term reservoir monitoring, particularly for enhanced oil recovery (EOR) operations with water flooding and/or C0 2 injection. Hence, a number of systems have been proposed for performing such remote formation resistivity monitoring.
  • EOR enhanced oil recovery
  • ERT electrical resistivity tomography
  • the proposed systems employ galvanic electrodes which have been shown to suffer from variable and generally degrading contact resistance with the formation due to electrochemical degradation of the electrode, resulting in poor performance which is further exacerbated by temperature drift and electrochemical noise.
  • Such effects directly impair data quality and survey repeatability. See, e.g., J. Deceuster, O. Kaufmann, and V. Van Camp, 2013, "Automated identification of changes in electrode contact properties for long-term permanent ERT monitoring experiments” Geophysics, vol. 78 (2), E79-E94.
  • Such difficulties are most strongly associated with ERT on steel casing. See, e.g., P.
  • Crosswell electromagnetic (EM) tomography systems have been proposed as a non-permanent solution to reservoir monitoring. See, e.g., M.J. Wilt, D.L. Alumbaugh, H.F. Morrison, A. Becker, K.H. Lee, and M.Deszcz-Pan, 1995, "Crosswell electromagnetic tomography: System design considerations and field results" Geophvsics, 60 (3), 871-885.
  • the proposed crosswell EM tomography systems involve the wireline deployment of inductive transmitters and receivers in separate wells. However, the wells in a typical oilfield are cased with carbon steel casing, which is both highly conductive and magnetically permeable. Hence, the magnetic fields external of the casing are greatly reduced.
  • the casing is typically inhomogeneous, having variations in casing diameter, thickness, permeability, and conductivity, resulting from manufacturing imperfections or from variations in temperature, stress, or corrosion after emplacement. Without precise knowledge of the casing properties, it is difficult to distinguish the casing-induced magnetic field effects from formation variations. See discussion in E. Nichols, 2003, "Permanently emplaced electromagnetic system and method of measuring formation resistivity adjacent to and between wells" US Patent 6,534,986.
  • FIG. 1 shows an illustrative permanent EM monitoring system for a reservoir.
  • FIG. 2 shows a related EM monitoring system configuration with a second downhole electrode.
  • FIG. 3 shows an enlarged cross-sectional view of a source electrode coupled to a casing string downhole.
  • FIG. 4 illustrates an armored cable doubling as a source electrode downhole.
  • FIG. 5 is a flow chart of an illustrative permanent EM current generation method.
  • Certain disclosed system and method embodiments provide a permanent electromagnetic (EM) monitoring system.
  • the EM system includes a casing string having a source electrode coupled thereto and cemented inside a borehole drilled in a formation.
  • An electrically insulating layer is arranged on an outer surface of the source electrode to provide a capacitive coupling between the source electrode and the formation.
  • the source electrode is driven relative to a return electrode by an alternating current (AC) power supply, thereby injecting current into the formation via the capacitive coupling.
  • a processing unit may determine properties of the formation based on spatially diverse sensor measurements and/or on the relationship between the current and the voltage between the electrodes.
  • the return electrode may be arranged at the Earth's surface, or alternatively attached to the same casing string as the source electrode. In further embodiments, the return electrode may be attached to another casing string in a different borehole. Additional source electrodes and/or additional return electrodes may be provided to increase the spatial diversity of the formation property measurements, and multiple measurement frequencies may be employed to yield additional measurement information.
  • the source electrode is preferably, though not necessarily, insulated from the casing string. In some embodiments the source electrode may take the form of an elongated conductor encased by the electrically insulating layer, where the electrically insulating layer has one or more regions of reduced thickness which accordingly concentrate the capacitive coupling and injected current.
  • FIG. 1 shows an illustrative permanent EM monitoring system 100 for a reservoir, with a first well 102 having a casing string 106 set within a borehole 104 and secured in place by a cement sheath 108.
  • a production tubing string 110 defines an annular flow path (between the walls of the casing string and the production tubing string) and an inner flow path (along the bore of the production tubing string).
  • Wellhead valves 112 and 114 provide fluid communication with the bottom-hole region via the annular and inner flow paths, respectively.
  • Well 102 may function as a production well, an injection well, or simply as a formation monitoring well.
  • Well 102 includes an armored cable 116 strapped to the outside of the casing string 106 to provide an insulated electrical connection to a source electrode 118 also attached to the casing string 106 downhole.
  • a power supply 120 operates as an AC voltage or current source to drive a current between the source electrode 118 and one or more return electrodes 122 located at a distance from the source electrode 118 and the well 102. In one embodiment, as depicted, the power supply 120 drives current to the source electrode 118 via the armored cable 116.
  • current may be driven to the source electrode 118 via the casing string 106 if adequate electrical isolation exists between the casing string and the formation.
  • the source electrode 118 may be powered via a downhole power supply such as a battery pack or downhole power generator.
  • additional distributed return electrodes 122 may be employed.
  • the return electrodes 122 may include the casing string in another well.
  • the source electrode 118 is preferably insulated from the casing string 106, and the cement 108 may be formulated to create a sheath that is relatively nonconductive (compared to the formation).
  • a centralizer fin, arm, or spring may optionally be provided to maintain contact or at least proximity between the source electrode 118 and the borehole wall.
  • another cable 132 is strapped to the outside of the casing string. It includes an array of optical transducers 134a, 134b, 134c, which can be interrogated via an optical fiber in cable 132.
  • Optical transducers 134 are each coupled to a pair of separated sensing electrodes 136, 137, 138, and 139.
  • optical transducer 134a is coupled between sensing electrodes 136 and 137
  • optical transducer 134b is coupled between sensing electrodes 137 and 138
  • optical transducer 134c is coupled between sensing electrodes 138 and 139.
  • each optical transducer is coupled to a dedicated pair of sensing electrodes.
  • the electrode spacing is a design parameter that can be adjusted to the desired application. Larger spacings provide larger investigation volumes at the cost of reduced spatial resolution.
  • the sensing electrodes 136-139 are preferably insulated from the casing string and may be held in contact or proximity with the borehole wall by a centralizer element or other mechanism. Such insulation can be provided by making the casing (at least in the proximity of the sensing electrode) from a non-conductive material such as fiberglass. Alternatively, a layer of such non-conductive material may surround the casing in the vicinity of the sensing electrode and/or serve as an insulating substrate for the sensing electrode. (Similar measures may be employed on casing string 106 to electrically isolate the source electrode 118 from the casing.)
  • Electric fields translate into potential differences between the sensing electrodes.
  • the optical transducers 134 employ this potential difference to modify some property of the light that propagates along cable 132.
  • An interface unit 140 includes an interrogator that transmits light along cable 132 and analyzes the return signal to detect the effects of optical transducers 134a-c and extract the corresponding electric field measurements.
  • Interface unit 140 is further coupled to a wired or wireless network 144 to communicate the measurement information to a processing unit 142 for further analysis and display to a user.
  • Processing unit 142 may be a computer in tablet, notebook, laptop, or portable form, a desktop computer, a server or virtual computer on a network, a mobile phone, or some combination of like elements that couple software-configured processing capacity to a user interface.
  • the processing may include compiling a time series of measurements to enable monitoring of the time evolution, and may further include the use of a geometrical model of the reservoir that takes into account the relative positions and configurations of the transducer modules and inverts the measurements to obtain one or more parameters. Those parameters may include a resistivity distribution and an estimated water saturation.
  • the processing unit 142 may determine a formation property based at least in part on a relationship, such as a ratio, between a voltage and current between the source electrode 118 and return electrodes 122.
  • the processing unit 142 may further enable the user to adjust the configuration of the system, modifying such parameters as firing rate of the source electrode 118, firing sequence, transmit amplitudes, transmit waveforms, transmit frequencies, receive filters, and demodulation techniques.
  • the computer further enables the user to adjust injection and/or production rates to optimize production from the reservoir.
  • Fig. 2 shows a related EM monitoring system configuration with a downhole return electrode 222 spatially separated from the source electrode 118.
  • Power supply 120 is coupled between the source and return electrodes 118, 222 by cables 116 to drive a current between the downhole electrodes.
  • Both electrodes 118, 222 are preferably in contact or proximity to the borehole 104 wall and insulated from the casing 106, so as to promote current flow through the formation.
  • the two electrode configuration enables the transmitter to emulate an electric dipole.
  • an array of sensing electrodes 136- 139 may be located in the same or a nearby well to obtain responsive electric field measurements.
  • the use of galvanic electrodes leads to electrochemical effects that may obscure and degrade the desired signal generation from the source electrodes 118, 222.
  • the solid metal or metal/metal-salt such as Ag/AgCl
  • a double-layer contact region forms to provide for the transition from electronic conduction in the metal to ionic conduction in the formation.
  • the electrochemistry of this double-layer is complex, but invariably results in a non- trivial resistance to current flow.
  • the impedance will vary with time, temperature, and ionic species concentrations.
  • FIG. 3 is an enlarged cross-sectional view of the source electrode 118 coupled to the casing string 106 cemented within the borehole 104.
  • the configuration depicted may be similar to the well system 102 of FIG. 1 and therefore may be best understood with reference thereto, where like numerals represent like elements that will not be described again in detail. More specifically, FIG. 3 includes the source electrode 118 arranged downhole and the return electrode 122 at the earth's surface, with the power supply 120 arranged therebetween.
  • An electrically insulating layer 302 is disposed on an outer surface 304 of the source electrode 118 (i.e., the surface of the source electrode 118 otherwise exposed to the cement and/or formation fluids).
  • the electrically insulating layer 302 may be a treatment or chemical coating on the outer surface 304 to reduce or substantially prevent reactivity with formation fluids. Such treatments also create an electrically insulating layer that prevents electron flow between the electrode 118 and the formation.
  • a useful degree of capacitive coupling can still be achieved, particularly if the electrically insulating layer 302 is kept thin and/or formed from a material having a high dielectric constant.
  • such layers are extremely robust and/or self-healing to minimize the effects of any scrapes or scratches during emplacement and lifetime of the well.
  • the source electrode 118 may be flat, curved, or textured in nature, thereby providing an increased surface area for enhancing the capacitive coupling.
  • the source electrode 118 may include fins, pins, ridges, projections, surface textures, and porous or expanded mesh materials. Conformal shapes (e.g., to match the borehole wall) or deformable materials may also be employed to further improve coupling between the source electrode 118 and the formation.
  • the capacitive coupling of the source electrode 118 with the formation may be increased by increasing the dielectric constant or decreasing the thickness of the electrically insulating layer 302.
  • I is the applied current
  • V is the applied voltage
  • R is the resistance of the earth
  • i is the imaginary portion
  • ⁇ is the angular frequency.
  • the resistance and frequency may be chosen such that R is substantially less than—— , thus resulting in the manipulated equation 3 :
  • the source electrode 118 may be coated with a non-reactive material using a vapor coating technique (or other deposition method). Suitable non- reactive materials may include glass, ceramic, nitrides, resin, fiberglass, vulcanized rubber, and suitable polymers. Alternatively, the source electrode 118 may be formed or coated with a material that readily forms a protective oxide layer, e.g., aluminum, tantalum, and/or titanium. Elemental aluminum, for example, oxides in air and may form a 4 nm thick electrically insulating layer 302 of electrically insulating aluminum oxide, and an anodizing process may be employed to enhance this layer. Advantageously, such layers are self-healing, reforming after being scratched or scraped away. Titanium oxide may be particularly well suited for long term downhole use. Corrosive treatments may alternatively or additionally be used to further accelerate the formation of such layers.
  • a vapor coating technique or other deposition method.
  • Suitable non- reactive materials may include glass, ceramic, nitrides,
  • the system 102 may further include a second electrically insulating layer 306 arranged between the electrode 118 and the casing string 106.
  • the second electrically insulating layer 306 may assist preventing short circuiting of the current back to the casing string 106, doing so by covering all or a portion of the casing string 106.
  • the casing string 106 may be constructed of a non- conductive material, such as fiber-glass. Such embodiments may help to enable operation of the source electrode 118 and overall system 102 within industry standards, such as the Intelligent Well Interface Standards (I WIS).
  • I WIS Intelligent Well Interface Standards
  • FIG. 4 illustrates another embodiment of the source electrode 118, where one or more regions of the armored cable 116 double as the source electrode 118.
  • the armored cable 116 includes an elongated conductor 402 surrounded by an electrically insulating layer 404 and further surrounded in most areas by armor or some other form of a conductive shield 406.
  • the electrically insulating layer 404 may be similar to the electrically insulating layer 302 previously discussed. As depicted, the insulation 404 may have one or more regions (e.g., region A) of reduced thickness, thereby concentrating the capacitive coupling and injected current in corresponding regions.
  • the capacitive coupling increases as the electrically insulating layer 404 thickness (d) decreases, therefore it follows that the region A (having a reduced electrically insulating layer 404 thickness) may emit a greater current than the region B (having an increased electrically insulating layer 404 thickness).
  • the armored cable 116 may dually serve to deliver power downhole and also serve as the source electrode 118 at predetermined depths.
  • FIG. 5 is a flow diagram of an illustrative permanent EM monitoring method.
  • the method begins at block 502 with a crew coupling a source electrode to a casing string.
  • the casing string and source electrode may then be run into a borehole and cemented therein for permanent monitoring.
  • the source electrode may have an electrically insulating layer arranged on an outer surface thereof which provides capacitive coupling between the source electrode and the formation.
  • the electrically insulating layer may be formed by oxidization, for example, when the source electrode is aluminum and interaction with air forms an aluminum oxide layer.
  • the source electrode may be coated with a non-reactive material.
  • power may be supplied to the source electrode, thereby injecting current into the formation via the capacitive coupling through the electrically insulating layer.
  • the current may be received by a return electrode, and in some embodiments, the current may be focused into the formation by preventing coupling back to the casing with a second insulation layer arranged between the source electrode and the casing.
  • the second insulation layer may extend along only the portion of casing near the source electrode or may alternatively extend the entire casing length.
  • the current may also be focused by a focus electrode additionally arranged downhole proximate to the source electrode.
  • the current may be focused by design of the source electrode, where the source electrode comprises an elongated conductor encased by the electrically insulating layer which has one or more regions of reduced thickness to concentrate the capacitive coupling and injected current in the one or more regions.
  • the return electrode may be arranged at the Earth's surface, on the same casing string as the source electrode, or on the casing string within another well.
  • the return electrode is connected to a processing unit capable of determining a formation property based at least in part on the current received by the return electrode as at block 508.
  • the source electrode may be supplemented with guard electrodes to focus the current injected from the source electrode deeper into the formation before it disperses. It is intended that the following claims be interpreted to embrace all such modifications, equivalents, and alternatives where applicable.
  • a permanent electromagnetic (EM) monitoring system that includes a casing string positioned inside a borehole penetrating a formation, a source electrode attached to the casing, an electrically insulating layer on an outer surface of the source electrode that provides a capacitive coupling of the source electrode to the formation, a power supply coupled to the source electrode which injects electrical current into the formation via the capacitive coupling, and a processing unit that determines a formation property based on at least the current received by a return electrode.
  • EM electromagnetic
  • a permanent electromagnetic (EM) monitoring method that includes positioning a casing string in a borehole, said casing string having a source electrode attached thereto, electrically insulating said source electrode with an electrically insulating layer on an outer surface of the source electrode which provides capacitive coupling of said source electrode to the formation, supplying electrical power to the source electrode with a power supply to inject current into the formation via said capacitive coupling, thereby producing a voltage, and determining a formation property with a processing unit based on at least the current received by a return electrode.
  • EM permanent electromagnetic
  • Each of embodiments A and B may have one or more of the following additional elements in any combination:
  • Element 1 A return electrode coupled to the power supply, and a processing unit that determines a formation property based at least in part on a relationship between the current and a voltage between the source and return electrodes.
  • Element 2 The processing unit further incorporates measurements from one or more sensing electrodes to determine the formation property.
  • Element 3 The power supply is coupled to a return electrode that provides a remote ground point at the Earth's surface.
  • Element 4 The power supply is coupled to a return electrode attached to said casing string.
  • Element 5 The power supply is coupled to a return electrode attached to another casing string in a different borehole.
  • Element 6 The source electrode is textured to provide increased surface area for enhancing the capacitive coupling.
  • Element 7 The electrically insulating layer includes a material that is substantially non-reactive with fluids in the formation.
  • Element 8 The source electrode includes a conductive material and the electrically insulating layer is an oxide compound of the conductive material.
  • Element 9 The casing string is electrically insulated from the formation or comprises a non-conductive material.
  • Element 10 A second electrically insulating layer arranged between the source electrode and the casing string.
  • Element 11 The source electrode is part of a multi-electrode configuration having at least one focus electrode proximate to the source electrode.
  • the source electrode comprises an elongated conductor encased by the electrically insulating layer, and where the electrically insulating layer has one or more regions of reduced thickness to concentrate the capacitive coupling and injected current in the one or more regions.
  • Element 13 Where determining the formation property with the processing unit further comprises incorporating measurements from one or more sensing electrodes.
  • Element 14 Oxidizing the source electrode with an oxide compound, thereby forming the electrically insulating layer.
  • Element 15 Insulating the source electrode from the casing with a second electrically insulating layer arranged therebetween.
  • Element 16 Electrically insulating the casing from the formation.
  • Element 17 Focusing the current with a focus electrode arranged proximate to the source electrode.

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Abstract

La présente invention porte sur un système de surveillance électromagnétique (EM) permanent donné à titre d'exemple comprenant une colonne de tubage positionnée à l'intérieur d'un trou de forage pénétrant dans une formation, une électrode de source fixée à la colonne de tubage, une couche électriquement isolante sur une surface extérieure de l'électrode de source qui fournit un couplage capacitif de l'électrode de source à la formation, une alimentation électrique couplée à l'électrode de source qui injecte un courant électrique dans la formation par l'intermédiaire du couplage capacitif, et une unité de traitement qui détermine une propriété de formation sur la base d'au moins le courant reçu par une électrode de retour.
PCT/US2014/031731 2014-03-25 2014-03-25 Systèmes de surveillance électromagnétique (em) permanent utilisant des électrodes de source couplées de manière capacitive WO2015147800A1 (fr)

Priority Applications (5)

Application Number Priority Date Filing Date Title
CA2940029A CA2940029A1 (fr) 2014-03-25 2014-03-25 Systemes de surveillance electromagnetique (em) permanent utilisant des electrodes de source couplees de maniere capacitive
EP14887671.7A EP3102955A4 (fr) 2014-03-25 2014-03-25 Systèmes de surveillance électromagnétique (em) permanent utilisant des électrodes de source couplées de manière capacitive
PCT/US2014/031731 WO2015147800A1 (fr) 2014-03-25 2014-03-25 Systèmes de surveillance électromagnétique (em) permanent utilisant des électrodes de source couplées de manière capacitive
US15/118,073 US10775527B2 (en) 2014-03-25 2014-03-25 Permanent EM monitoring systems using capacitively coupled source electrodes
AU2014388388A AU2014388388B2 (en) 2014-03-25 2014-03-25 Permanent EM monitoring systems using capacitively coupled source electrodes

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/US2014/031731 WO2015147800A1 (fr) 2014-03-25 2014-03-25 Systèmes de surveillance électromagnétique (em) permanent utilisant des électrodes de source couplées de manière capacitive

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US (1) US10775527B2 (fr)
EP (1) EP3102955A4 (fr)
AU (1) AU2014388388B2 (fr)
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WO2017086956A1 (fr) * 2015-11-18 2017-05-26 Halliburton Energy Services, Inc. Surveillance d'injections d'eau à l'aide de potentiels entre des électrodes montées sur un tubage
WO2018017081A1 (fr) * 2016-07-20 2018-01-25 Haliburton Energy Services, Inc. Systèmes de couplage capacitif de fond
WO2018063162A1 (fr) * 2016-09-27 2018-04-05 Halliburton Energy Services, Inc. Étalonnage d'outils de télémétrie électromagnétique
WO2018156125A1 (fr) * 2017-02-22 2018-08-30 Halliburton Energy Services, Inc. Amélioration de la plage dynamique de mesures d'électrode
US10775527B2 (en) 2014-03-25 2020-09-15 Halliburton Energy Services, Inc. Permanent EM monitoring systems using capacitively coupled source electrodes
GB2616472A (en) * 2022-03-11 2023-09-13 Qinetiq Ltd Capacitive-resistive imaging system
GB2627902A (en) * 2022-03-11 2024-09-04 Qinetiq Ltd Capacitive-resistive imaging system

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US10450852B2 (en) * 2014-12-11 2019-10-22 Halliburton Energy Services, Inc. Formation monitoring through the casing
US11073013B2 (en) * 2014-12-18 2021-07-27 Schlumberger Technology Corporation Electric dipole surface antenna configurations for electromagnetic wellbore instrument telemetry
US9983329B2 (en) * 2015-06-05 2018-05-29 Halliburton Energy Services, Inc. Sensor system for downhole galvanic measurements
DE102015111658B4 (de) * 2015-07-17 2018-11-29 Capical Gmbh System, Verfahren und Computerprogramm zur kapazitiven Erfassung von elektrischen Biosignalen
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US20160356911A1 (en) 2016-12-08
EP3102955A4 (fr) 2017-10-04
AU2014388388A1 (en) 2016-09-01
AU2014388388B2 (en) 2017-11-23
CA2940029A1 (fr) 2015-10-01
EP3102955A1 (fr) 2016-12-14

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